Monitor and control of directional drilling operations and simulations

ABSTRACT

Various embodiments include apparatus and methods that use hand mobile communications device with respect to a drilling operation at a drilling site. Data with respect to one or more sensors downhole at a drilling site can be wirelessly received in the hand mobile communications device. Representations of the received data can be displayed on a graphical user interface screen of the hand mobile communications device. The representations can include displaying the data in a graphical representation, a numerical representation, or a graphical and numerical representation on the graphical user interface screen. Additional apparatus, systems, and methods are disclosed.

RELATED APPLICATIONS

This application is a continuation-in-part of U.S. application Ser. No.12/442,037, filed Feb. 9, 2010, which is a U.S. National Stage Filingunder 35 U.S.C. 371 from International Application NumberPCT/US2007/020867, filed Sep. 27, 2007 and published in English as WO2008/039523 A1 on Apr. 3, 2008, which claims the benefit under U.S.Provisional Application Ser. No. 60/827,209, filed Sep. 27, 2006, under35 U.S.C. 119(e), which applications and publication are incorporatedherein by reference in their entirety.

TECHNICAL FIELD

The application relates generally to downhole drilling. In particular,the application relates to a monitoring and control of directionaldrilling operations and simulations.

BACKGROUND

Directional drilling operations typically allow for greater recovery ofhydrocarbons from reservoirs downhole.

BRIEF DESCRIPTION OF THE DRAWINGS

Embodiments of the invention may be best understood by referring to thefollowing description and accompanying drawings which illustrate suchembodiments. In the drawings:

FIG. 1 illustrates a system for drilling operations, according to someembodiments of the invention.

FIG. 2 illustrates a computer that executes software for performingoperations, according to some embodiments of the invention.

FIG. 3 illustrates a graphical user interface (GUI) screen that allowsfor controlling and monitoring of a directional drillingoperation/simulation, according to some embodiments of the invention.

FIG. 4 illustrates a GUI screen that allows for controlling andmonitoring of a directional drilling operation/simulation, according tosome other embodiments of the invention.

FIG. 5 illustrates a GUI screen that allows for controlling andmonitoring of a directional drilling operation/simulation, according tosome other embodiments of the invention.

FIG. 6 illustrates a GUI screen that allows for controlling andmonitoring of a directional drilling operation/simulation, according tosome other embodiments of the invention.

FIG. 7 illustrates a GUI screen that allows for controlling andmonitoring of a directional drilling operation/simulation, according tosome other embodiments of the invention.

FIG. 8 illustrates a GUI screen that allows for controlling andmonitoring of a directional drilling operation/simulation, according tosome other embodiments of the invention.

FIG. 9 illustrates a report generated for a directional drillingoperation/simulation, according to some embodiments of the invention.

FIGS. 10-11 illustrate another set of reports for a directional drillingoperation/simulation, according to some embodiments of the invention.

FIG. 12 illustrates a drilling operation wherein the reamer is notengaged and the drill bit is on the bottom, according to someembodiments of the invention.

FIGS. 13-14 illustrate graphs of the torque relative to the operatingdifferential pressure for a downhole drilling motor or a rotarysteerable tool, according to some embodiments of the invention.

FIGS. 15A-15C show examples of hand mobile communication devicesoperable to be structured to monitor and control drilling operations andassociated functions at drilling sites and simulations thereof, inaccordance with various embodiments.

FIG. 16 illustrates an example architecture for monitoring andcontrolling a drilling operation at a drilling site using a hand mobilecommunication device, in accordance with various embodiments.

FIG. 17 shows features of an example method to monitor and control adrilling operation using a hand mobile communication device, inaccordance with various embodiments.

FIG. 18 shows example components of a hand mobile communication deviceoperable to monitor and control drilling operations, in accordance withvarious embodiments.

DETAILED DESCRIPTION

Methods, apparatus and systems for monitor and control of directionaldrilling operations/simulations are described. In the followingdescription, numerous specific details are set forth. However, it isunderstood that embodiments of the invention may be practiced withoutthese specific details. In other instances, well-known circuits,structures and techniques have not been shown in detail in order not toobscure the understanding of this description.

This description of the embodiments is divided into five sections. Thefirst section describes a system operating environment. The secondsection describes a computer operating environment. The third sectiondescribes graphical and numerical representations for a directionaldrilling operation/simulation. The fourth section describes loadmonitoring among downhole components. The fifth section provides somegeneral comments.

Embodiments allow for monitoring and controlling of directional drillingoperations and simulations. Embodiments may include graphical andnumerical output of data received and processed from different sensors(including those at the surface and downhole). A ‘rotary’ drillingbottom hole assembly (BHA), downhole drilling motor, drilling turbine ordownhole drilling tool such as a rotary steerable tool allows fordirectional drilling. The functioning of a BHA, downhole drilling motor,drilling turbine or rotary steerable tool in the dynamic downholeenvironment of an oilwell is relatively complex since operatingparameters applied at surface (such as flow rate, weight on bit anddrill string rotation rate) are combined with other characteristics ofthe downhole drilling operation. These other characteristics includeformation characteristics (such as rock strength and geothermaltemperature), characteristics of additional tools that are incorporatedin the BHA (such as the drill bit), characteristics of the drillingfluids (such as lubricity), etc.

The application of sub-optimal operating parameters, excessive operatingparameters and the undertaking of inappropriate actions during specificfunctional occurrences during motor operations downhole, are some of theproblems that are encountered during a directional drilling operation.

Design engineers, support engineers, marketing personnel, repair andmaintenance personnel and various members of a customer's personnel maynever be present on a rig floor. Also there can be an effectivedisconnection between the directional driller on the rig floor and afunctioning BHA, downhole drilling motor, drilling turbine or rotarysteerable tool, thousands of feet below surface. Therefore, such personsdo not have an accurate appreciation of the effect that surface appliedoperating parameters and the downhole operating environment can have ona drilling motor, drilling turbine or a rotary steerable tool as themotor/tool functions downhole.

Using some embodiments, operations personnel, design engineers, supportengineers, marketing personnel, repair and maintenance personnel andcustomers can potentially add to their understanding of BHAs, downholedrilling motors, drilling turbines and rotary steerable tools in termsof the rig floor applied operating parameters and the resulting loadsthat they produce on motors/tools, which ultimately affect motor/toolperformance. A more advanced understanding of the functioning of BHAs,downhole drilling motors, drilling turbines or rotary steerable tools bypersonnel from various disciplines would produce benefits form thedesign phase through to the post-operational problem investigation andanalysis phase.

Embodiments would allow users to effectively train on a simulatorthrough the control of the BHA, downhole drilling motor, drillingturbine or rotary steerable tool operations while avoiding the cost andpotential safety training issues normally associated with rigsite anddynamometer testing operations. Embodiments would encourage a betterunderstanding of the balance of motor/tool input and output with respectto the characteristics of the downhole operating environment and alsowith respect to motor/tool efficiency, reliability and longevity.

Some embodiments provide a graphical user interface (GUI) for monitoringa directional drilling operation. Some embodiments may be used in anactual drilling operation. Alternatively or in addition, someembodiments may be used in a simulation for training of operators fordirectional drilling. Data from sensors at the surface and downhole maybe processed. A graphical and numerical representation of the operationsdownhole may be provided based on the processed data. Some embodimentsmay illustrate the performance of the BHA, downhole drilling motor,drilling turbine and rotary steerable tool used in directional drillingoperations. Some embodiments may graphically illustrate the rotationsper minute (RPMs) of and the torque applied by the downhole motor,drilling turbine or rotary steerable tool, the operating differentialpressure across the motor, turbine, tool, etc. A cross-sectional view ofthe motor, turbine, tool within the drill string may be graphicallyshown. This view may show the rotations of the drill string incombination with the motor, turbine, and tool. Accordingly, the drillermay visually track the speed of rotation of the drilling motor/rotarysteerable tool and adjust if necessary. The following description andaccompanying figures describe the monitoring and control of a drillingmotor. Such description is also applicable to various types of rotaryBHA's, drilling turbines and rotary steerable tools.

FIG. 1 illustrates a system for drilling operations, according to someembodiments of the invention. FIG. 1 illustrates a directional drillingoperation. The drilling system comprises a drilling rig 10 at thesurface 12, supporting a drill string 14. In some embodiments, the drillstring 14 is an assembly of drill pipe sections which are connectedend-to-end through a work platform 16. In alternative embodiments, thedrill string comprises coiled tubing rather than individual drill pipes.A drill bit 18 couples to the lower end of the drill string 14, andthrough drilling operations the bit 18 creates a borehole 20 throughearth formations 22 and 24. The drill string 14 has on its lower end abottom hole (BHA) assembly 26 which comprises the drill bit 18, alogging tool 30 built into collar section 32, directional sensorslocated in a non-magnetic instrument sub 34, a downhole controller 40, atelemetry transmitter 42, and in some embodiments a downholemotor/rotary steerable tool 28.

Drilling fluid is pumped from a pit 36 at the surface through the line38, into the drill string 14 and to the drill bit 18. After flowing outthrough the face of the drill bit 18, the drilling fluid rises back tothe surface through the annular area between the drillstring 14 theborehole 20. At the surface the drilling fluid is collected and returnedto the pit 36 for filtering. The drilling fluid is used to lubricate andcool the drill bit 18 and to remove cuttings from the borehole 20.

The downhole controller 40 controls the operation of telemetrytransmitter 42 and orchestrates the operation of downhole components.The controller processes data received from the logging tool 30 and/orsensors in the instrument sub 34 and produces encoded signals fortransmission to the surface via the telemetry transmitter 42. In someembodiments telemetry is in the form of mud pulses within the drillstring 14, and which mud pulses are detected at the surface by a mudpulse receiver 44. Other telemetry systems may be equivalently used(e.g., acoustic telemetry along the drill string, wired drill pipe,etc.). In addition to the downhole sensors, the system may include anumber of sensors at the surface of the rig floor to monitor differentoperations (e.g., rotation rate of the drill string, mud flow rate,etc.).

In some embodiments, the data from the downhole and the surface sensorsis processed for display (as further described below). The processorcomponents that process such data may be downhole and/or at the surface.For example, one or more processors in a downhole tool may process thedownhole data. Alternatively or in addition, one or more processorseither at the rig site and/or at a remote location may process the data.Moreover, the processed data may then be numerically and graphicallydisplayed (as further described below).

An example computer system, which may be used to process and/or displaythe data is now described. In particular, FIG. 2 illustrates a computerthat executes software for performing operations, according to someembodiments of the invention. The computer system 200 may berepresentative of various components in the system 200. For example, thecomputer system 200 may be representative of parts of the downhole tool,a computer local to the rig site, a computer remote to the rig site,etc.

As illustrated in FIG. 2, the computer system 200 comprises processor(s)202. The computer system 200 also includes a memory unit 230, processorbus 222, and Input/Output controller hub (ICH) 224. The processor(s)202, memory unit 230, and ICH 224 are coupled to the processor bus 222.The processor(s) 202 may comprise any suitable processor architecture.The computer system 200 may comprise one, two, three, or moreprocessors, any of which may execute a set of instructions in accordancewith embodiments of the invention.

The memory unit 230 may store data and/or instructions, and may compriseany suitable memory, such as a dynamic random access memory (DRAM). Thecomputer system 200 also includes IDE drive(s) 208 and/or other suitablestorage devices. A graphics controller 204 controls the display ofinformation on a display device 206, according to some embodiments ofthe invention.

The input/output controller hub (ICH) 224 provides an interface to I/Odevices or peripheral components for the computer system 200. The ICH224 may comprise any suitable interface controller to provide for anysuitable communication link to the processor(s) 202, memory unit 230and/or to any suitable device or component in communication with the ICH224. For one embodiment of the invention, the ICH 224 provides suitablearbitration and buffering for each interface.

For some embodiments of the invention, the ICH 224 provides an interfaceto one or more suitable integrated drive electronics (IDE) drives 208,such as a hard disk drive (HDD) or compact disc read only memory (CDROM) drive, or to suitable universal serial bus (USB) devices throughone or more USB ports 210. For one embodiment, the ICH 224 also providesan interface to a keyboard 212, a mouse 214, a CD-ROM drive 218, one ormore suitable devices through one or more firewire ports 216. For oneembodiment of the invention, the ICH 224 also provides a networkinterface 220 though which the computer system 200 can communicate withother computers and/or devices.

In some embodiments, the computer system 200 includes a machine-readablemedium that stores a set of instructions (e.g., software) embodying anyone, or all, of the methodologies for described herein. Furthermore,software may reside, completely or at least partially, within memoryunit 230 and/or within the processor(s) 202.

Directional drilling is based on decisions being made by the directionaldriller which are the result of information being made available to thedriller at the rig floor, in logging units at the rig site (not at therig floor), and on the directional driller's conceptions about equipmentperformance and functioning. The decisions made by the directionaldriller have a direct bearing on the drilling operating parametersapplied at surface to drilling tools downhole. Embodiments provide forreal time representation of comprehensive directional drilling data atrig floor (on an intrinsically safe computer or purged driller's controlunit or “dog house”), at rig site (data logging unit or office) andremotely (office or dedicated Remote Technical Operations (RTO) Centerof the directional drilling supplier and/or oil company).

An important part of the directional drilling process is the interactionof the drill bit with the formation in terms of the torque and RPMapplied to the drill bit and the loading imparted into the formation tolocally fail and remove the formation. Another important part is how thetorque and RPM applied at the drill bit causes reactive mechanicalloadings in the bottom hole drilling assembly tools which affect thetrajectory of the hole drilled.

Maintaining a consistent level of torque and revolutions on the drillbit may achieve and maintain good formation penetration rate, good holedirectional control, etc. Moreover, this consistent level allows themaximization of the reliability and longevity of various downholedrilling tools in the bottom hole drilling assembly (fluctuatingmechanical and pressure loadings accelerate the wear and fatigue ofcomponents).

While drilling, the drill bit has a number of sources of excitation andloading. These sources may cause the bit speed to fluctuate, the bit tovibrate, the bit to be excessively forced into the formation, and insome cases the bit to actually bounce off the hole bottom. Theapplication of weight to the bit (by slacking off the rig hook load) maybe a source of excitation and loading. There can be a number of thesesources, which can negatively affect the face of the drill bit andformation interaction. For example, some of the weight applied atsurface at times is not transmitted to the drill bit because thedrillstring and bottom hole assembly contact the casing and hole wallcausing substantial frictional losses. The drill string can thensuddenly “free-off” resulting in remaining, previously hung-up weight,being abruptly transferred to the drill bit with resulting heavyreaction loadings being applied to the tools (internals and housings) inthe bottom hole drilling assembly. Another example of such a sourcerelates to the application of torque at the surface. At times, not allof the torque is transmitted to the drill bit. The drill string may besubsequently freed, such that high torsional loadings may be abruptlyapplied to tools in the bottom hole drilling assembly.

Another example of sources of excitation and loading relate to floatingsemi-submersible drilling rigs and drillships. In such operations, theconsistent application of weight to the bit is undertaken via the use ofwave heave compensators. However, these compensators can often not be100% effective and harsh weather can also exceed their capability.Weight applied at the bit fluctuates significantly, which can causegreat difficulty when undertaking more precise directional controldrilling operations. In some cases the bit can actually lift off bottom.

The above scenarios are often not observable at surface by thedirectional driller. Embodiments may process relevant data. Throughgraphic and numerical representation, embodiments may indicatefluctuations in the drill bit rotation and in drilling motor/rotarysteerable tool output torque and RPM characteristics. The groupedpresentation of this data has not been previously available to the liverig floor directional drilling process. Embodiments also allow suchevents to be considered in detail from recorded well data andcontingencies to be established. Some embodiments are applicable torotary drilling assemblies where there is no drilling motor in thebottom hole drilling assembly, such as rotary steerable drillingassemblies.

Until now the data which is available in relation to the directionaldrilling process has not been available to the directional driller inreal time in one location. Moreover, conventional techniques haverequired a significant level of conception by the directional drillerand ideally have included interpretation and input by specialists otherthan the directional driller who are not present on the rig floor. Asthe electronic instrumentation of downhole drilling tools continues todevelop, ever increasing amounts of data are becoming available fromdownhole on which the directional drilling process can be made moreefficient and effective.

Embodiments provide a central platform on which to display dynamicnumerical and graphical data together. In addition to displaying datagenerated by sensors contained within downhole tools, embodiments mayprovide a platform where alongside sensor data, very recently developedand further developing cutting-edge directional drilling engineeringmodeling data, can be jointly displayed. Moreover, embodiments mayinterpret and provide a dynamic indication of occurrences downhole thathave to date otherwise gone unnoticed live at the rig floor by thedirectional driller (e.g. drilling motor/rotary steerable toolmicro-stalling, downhole vibration, and drill bit stick-slip, etc.).

Embodiments may also process data and display to the directional drillerthe level of loading being applied to downhole tools in terms of overallefficiency of the drilling system, mechanical loadings such as fatiguetendencies and estimated reliability of specific downhole tools. This ineffect provides the directional driller with a far more comprehensivepicture and understanding of the complete directional drilling processbased on dynamic numerical data (sensors and modeled data), dynamicgraphics, and estimations or look-aheads in terms of equipmentreliability (based on empirical knowledge, dynamometer testing data andengineering design data). The data may be obtained direct from surfaceand downhole sensors and from modeled data based on sensor data inputsprocessed by the embodiments. The processing may be based on dataobtained from dynamometer testing, and via drilling industry and classicengineering theory. Embodiments provide dynamic graphics and digitalestimations or look-aheads in terms of both the directional drillingbehavior of the downhole drilling assembly and downhole drillingequipment reliability.

An important component to many directional drilling applications is theoptimum application of downhole drilling motors and rotary steerabletools. Embodiments may provide dynamic graphical and numericalrepresentations of drilling motors and rotary steerable tools inoperation in terms of the differential operating pressure across motorsand loadings applied by the drill string to rotary steerable tools.Furthermore, embodiments may provide dynamic drilling motor/rotarysteerable tool input/output performance graphs, to aid the directionaldriller's perception and decision making.

Embodiments allow for real time representation of drilling motor/rotarysteerable tool operating differential pressure for the directionaldrilling operation. Conventionally, the directional driller had toreference an off-bottom standpipe pressure value at rig floor inrelation to the dynamic on-bottom pressure value at rig floor. Thedriller could then deduce the resulting pressure differential andconceive the result of this in terms of motor/tool output torque andmotor/tool RPM (as applied to the bit). Embodiments show these pressuredifferentials and resulting torque and RPM values both through a dynamicperformance graph and a numerical representation. In some embodiments,the real time representations (as described) may be displayed local aswell as remote relative to the rig site.

Some embodiments may allow for simulation of a directional downholedrilling operation. Some embodiments offer an aid to the understandingof the functioning of a downhole drilling motor/rotary steerable tool byallowing the simulator operator to see and control the results of theirapplied motor/tool operating parameters real-time. The simulatoroperator may choose from various types of drilling conditions, maycontrol Weight On Bit (WOB), flow rate, drillstring rotation rate.Moreover, the operator may simultaneously see the resulting differentialpressure across the motor/tool.

The simulator operator may see where the resultant motor or rotarysteerable tool output torque and Rotations Per Minute (RPMs) figure on aperformance graph for the motor/tool. In some embodiments, the simulatoroperator may also see an animated cross sectional graphic of the rotorrotate/precess in the stator and may see the stator rotate due to theapplication of drillstring rotation (at 1:1 speed ratio or scaled downin speed for ease of viewing). The operator can also see motor/toolstalling, may get a feel for how much load is induced in the motor/tool,may see simulated elastomer heating and chunking, and may be given anindication of what effect this has on overall motor/tool reliability.

Some embodiments allow the operator to select optimum drillingparameters and objectives for particular drilling conditions and to tunethe process to provide an efficient balanced working system of inputsversus outputs. In some embodiments, once that control has been achievedand held, the system may project what the real life outcome should be interms of a sub-50 hr run or in excess of 50, 100,150, or 200 hr runs.Using some embodiments, simulator operators are encouraged to understandthat high Rate Of Penetration (ROP) and operations at high motor orrotary steerable tool loadings are to be considered against potentialtoolface control/stall occurrence issues and corresponding reducedreliability and longevity issues.

In some embodiments, problem scenarios may be generated by the systemand questions asked of the operator regarding the problem scenarios interms of weighing up the problem indications against footage/time leftto drill, drilling conditions, etc., in the particular application.Problem scenarios that are presented in relevant sections of a technicalhandbook may be referenced via hypertext links (i.e. the operator causesa motor/tool stall and they get linked to the items about ‘stall’ in thehandbook).

In some embodiments, the simulator may include a competitive user mode.For the ‘competitive user’ mode there is a scoring system option andranking table for sessions. Different objective settings could beselected (i.e. drill a pre-set footage as efficiently/reliably aspossible, or drill an unlimited footage until predicted tool problems orreduced tool wear/efficiency/reliability cause operations to bestopped). A score may be obtained which may be linked to one or more ofa number of parameters. The parameters may include one or more of thefollowing:

-   -   chosen operating settings given the drilling situation selected        by the user    -   maintaining operating parameters such that reliability of the        motor/tool is ensured, etc.    -   ROP/footage drilled    -   the number of stall occurrences    -   reactions to stall situations    -   the reaction to various problem occurrences that occur    -   overall process efficiency for the duration of the simulator        session

The simulator may allow for a number of inputs and outputs. With regardto inputs, the simulator may allow for a configuration of one or more ofthe following:

-   -   size and type of motor or rotary steerable tool (e.g., outside        diameter of the tool)    -   size and type of tool (e.g., motor, rotary steerable tool,        adjustable gauge stabilizer, etc.)    -   stator elastomer type: high temperature/low temperature    -   rotor/stator mating fit at surface: compression/size for        size/clearance high/low    -   rotor jet nozzle fitted? yes/no (allow user to go to calculator        from handbook) size?    -   motor bent housing angle setting    -   motor sleeve stabilizer gauge    -   string stabilizer gauge

Other inputs for the simulator may include one or more of the following:

-   -   General Formation Type say 1 to 5 (soft to hard formation)    -   Stringers In Formation?: Yes/No    -   Bit Type: Rollercone/PDC/Diamond    -   Bit Diameter    -   Bit Gauge    -   Bit Manufacturers Details/Serial Number    -   Bit Aggression Rating:    -   Bit Jets: number/sizes    -   Mud Type: Oil Base, Water Base, Pseudo Oil Base

Other inputs for the simulator may also include one or more of thefollowing:

-   -   Max WOB    -   Min/Max Flow Rate    -   Max String Rotation Rate    -   Minimum Acceptable ROP    -   Maximum ROP    -   Maximum Operating Differential Pressure    -   Maximum Reactive Torque From Motor/Tool    -   Downhole Operating Temperature    -   Temperature At Surface    -   Axial Vibration Level    -   Lateral Vibration Level    -   Torsional Vibration Level

Some real time operator control inputs may include one or more of thefollowing:

-   -   Drilling Mud Flow Rate (GPM)    -   Drillstring Rotation Rate (RPM)    -   Weight On Bit (KLbs)    -   Azimuth    -   Inclination

In some embodiments, the simulator may allow for different graphical andnumerical outputs, which may include one or more of the following:

-   -   Motor/Tool RPM/Torque/Horsepower performance graph with moving        cross hairs applied (performance graph indicating entry into the        transition zone and stall zone)    -   Animated cross sectional view of power unit rotor/stator showing        rotor rotation and precession    -   Motor/Tool operating differential pressure gauge indicating        entry into the transition zone and stall zone    -   Possible animated longitudinal cross section view of the power        unit rotor/stator which shows the drilling mud going between the        rotor and stator (rotor rotating and fluid cavities moving),        (may also include a view of the full motor/tool i.e. show fluid        flow over the transmission unit and through the        driveshaft/bearing assembly).    -   Drillstring RPM, mud pump GPM and WOB controllers    -   Motor/Tool output RPM and output torque    -   Actual bit RPM (drillstring RPM+motor/tool output RPM, allowing        for motor/tool volumetric inefficiency etc)    -   Actual, minimum, maximum and average ROP indicators    -   Overall efficiency/reliability indicator    -   Stall occurrence indicator    -   Current and overall response to events indicator (program puts        up items such a full or micro-stall, stringers, bit balling etc)    -   Various warning alarm noises incorporated

Other graphical and numerical outputs may include one or more of thefollowing:

-   -   Rotor/Stator Fit Change Due To Downhole Temperature    -   Elastomer temperature indicator    -   stator temperature/damage tendency (alarm on cracking, tearing,        chunking)    -   Cumulative footage drilled    -   for burst and overall ROP    -   reactive torque    -   the number of stalls indicator (micro and full)    -   time for reactions to stall situations    -   the overall process efficiency for the duration of the simulator        session/tie into reliability indicator

In some embodiments, other graphical and numerical outputs may includeone or more of the following:

-   -   Maximum WOB    -   Minimum/Maximum Flow Rate    -   Bit Whirl Outputs    -   Axial Vibration Level    -   Lateral Vibration Level    -   Torsional Vibration Level

In some embodiments, other graphical and numerical outputs may includeone or more of the following:

-   -   Real-time rotor/stator cross sectional animation    -   Analogue type standpipe pressure gauge animation    -   Interactive user controls: GPM, WOB, drillstring rotation rate    -   Stall Indicator, Micro Stall Indicator    -   User Screen Indicators:        -   WOB        -   Flow rate (minimum/maximum)        -   String RPM (maximum)        -   Motor/tool differential pressure        -   Motor/tool torque        -   Motor/tool output RPM        -   Actual bit RPM (string and motor)        -   Micro-stall occurrences        -   Full stall occurrences        -   Min acceptable ROP        -   Cumulative footage drilled        -   Elapsed time        -   Actual and Average ROP        -   Overall efficiency/reliability level, rating        -   Stator damage tendency        -   Formation (Basic)        -   General formation drillability type, i.e. 1 to 5 (easy to            hard drilling)

In some embodiments, other graphical and numerical outputs may includesome advanced outputs, which may include one or more of the following:

-   -   Rotor/Stator Fit Change Due To Downhole Temperature    -   Elastomer temperature indicator    -   stator temperature/damage tendency (alarm on cracking, tearing,        chunking)    -   Cumulative footage drilled    -   for burst and overall ROP    -   reactive torque    -   the number of stalls indicator (micro and full)

In some embodiments, the interface may include a tally book. The tallybook may display real-time recording of data and notes. The tally bookmay be an editable document that may be accessible for download forfuture reference. In some embodiments, the data that is displayed may berecorded and graphically replayed. Accordingly, drilling tool problemoccurrences may be analyzed and displayed to customers.

Some embodiments may be used for both actual and simulated drillingoperations for different modes including a motor Bottom Hole Assembly(BHA) and BHA with drilling motor and tools above and below (e.g.underreamer and rotary steerable tool), etc.

Various graphical user interface screens for display of graphical andnumerical output for monitoring and controlling of a drillingoperation/simulation are now described. FIG. 3 illustrates a graphicaluser interface (GUI) screen that allows for controlling and monitoringof a directional drilling operation/simulation, according to someembodiments of the invention. A GUI screen 300 includes a graph 302 thattracks the performance of the downhole motor. The graph 302 illustratesthe relationship among the motor flow rate and RPM, the operatingdifferential pressure across the downhole motor and the torque outputfrom the downhole motor. A graphic 303 of the GUI screen 300 illustratesgraphical and numerical data for the downhole drilling motor. A graphic304 illustrates a cross-section of a drill string 306 that houses adownhole motor 308. The downhole motor 308 may include a positivedisplacement type helically lobed rotor and stator power unit, where,for a given flow rate and circulating fluid properties, the operatingdifferential pressure across the power unit is directly proportional tothe torque produced by the power unit. As shown, the downhole motor 308includes a number of lobes on a rotor that fit into a number of lobedopenings in a stator housing 306. As the pressurized drilling fluidflows through the openings between the lobes, one or more of the lobesengage one or more of the openings, thereby enabling rotation. Thegraphic 304 may be updated based on sensors to illustrate the rotationof both the drill string 306 and the downhole motor 308. Accordingly,the drilling operator may visually track the rotation and adjust ifnecessary.

A graphic 305 illustrates a meter that tracks the differential pressureacross the downhole drilling motor. The graphic 303 also includesnumerical outputs for a number of attributes of the motor, drill bit anddrill string. For example, the graphic 303 includes numerical outputsfor the motor output RPMs, the drill string RPMs, the drill bit RPMs,the weight on bit, the power unit, the differential pressure, the rateof penetration, the flow rate and the motor output torque.

A graphic 310 of the GUI screen 300 illustrates the position of the BHA(including the depth in the borehole and the distance that the bit isfrom the bottom). A graphic 312 of the GUI screen 300 illustrates datarelated to drilling control (including brake/draw works, pumps androtary table/top drive). A graphic 314 of the GUI screen 300 provides adrilling data summary (including off bottom pressure, on bottompressure, flow rate, string RPM, bit RPM, weight on bit, motor outputtorque, hours for the current run, measured depth and average ROP).

A graphic 316 of the GUI screen 300 includes a number of buttons, whichallows for the units to be changed, to generate reports from thisdrilling operation, to perform a look ahead for the drilling operation,to remove the drill string from the borehole and to stop the drillingoperation/simulation.

FIG. 4 illustrates a graphical user interface (GUI) screen that allowsfor controlling and monitoring of a directional drillingoperation/simulation, according to some other embodiments of theinvention. A GUI screen 400 has some of the same graphics as the GUIscreen 300. In addition, the GUI screen 400 includes some additionalgraphics.

The GUI screen 400 includes a graphic 401. The graphic 401 illustratesthe position of the drill bit (including the depth in the borehole andthe distance that the bit is from the bottom). The GUI screen 400includes a graphic 402 that includes a summary of the reliability of thedrilling operation (including data related to stalling, rotor/stator fitand estimates of reliability). The GUI screen 400 includes a graphic 406that includes warnings of problems related to the drillingoperation/simulation, causes of such problems and corrections of suchproblems.

FIG. 5 illustrates a graphical user interface (GUI) screen that allowsfor controlling and monitoring of a directional drillingoperation/simulation, according to some other embodiments of theinvention. A GUI screen 500 has some of the same graphics as the GUIscreens 300 and 400. In addition, the GUI screen 500 includes someadditional graphics.

The GUI screen 500 includes a graphic 502 that illustrates the positionsof the different BHA components downhole. The BHA components illustratedinclude an under reamer, the downhole drilling motor and a rotarysteerable tool. The graphic 502 illustrates the distance from thesurface and from the bottom for these different BHA components. The GUIscreen 500 also includes a graphic 504 that illustrates drillingdynamics of the drilling operation. The drilling dynamics includenumerical outputs that include actual data for lateral vibration, axialvibration, torsional vibration and reactive torque. The drillingdynamics also include numerical outputs that include extreme vibrationprojection (including lateral, axial and torsional). The drillingdynamics also includes a BHA analysis for whirl, which tracks the speedsand cumulative cycles of the BHA.

FIG. 6 illustrates a graphical user interface (GUI) screen that allowsfor controlling and monitoring of a directional drillingoperation/simulation, according to some other embodiments of theinvention. A GUI screen 600 has some of the same graphics as the GUIscreens 300, 400 and 500. In addition, the GUI screen 600 includes someadditional graphics.

The GUI screen 600 includes a graphic 602 that illustrates weightmanagement of different parts of the BHA. The graphic 602 includes thetotal weight on bit and the percentages of the weight on the reamer andthe drill bit. The GUI screen 600 also includes a graphic 604 thatincludes help relative to the other graphics on the GUI screen 600.

FIG. 7 illustrates a graphical user interface (GUI) screen that allowsfor controlling and monitoring of a directional drillingoperation/simulation, according to some other embodiments of theinvention. A GUI screen 700 has some of the same graphics as the GUIscreens 300, 400, 500 and 600. In addition, the GUI screen 700 includessome additional graphics.

The GUI screen 700 includes a graph 702 that illustrates the performanceof a rotary steerable tool. In particular, the graph 702 monitors thetorsional efficiency of the rotary steerable tool relative to a minimumthreshold and a maximum threshold. The GUI screen 700 also includes agraphic 704. The graphic 704 includes a graphic 706 that illustrates thecurrent toolface of the bottom hole assembly. The toolface is anazimuthal indication of the direction of the bottom hole drillingassembly with respect to magnetic north. The toolface is referenced tothe planned azimuthal well direction at a given depth. The graphic 704also includes a graphic 708 that illustrates a meter that monitors thegearbox oil level. This meter may be changed to monitor other toolparameters such as the transmission, the clutch slip and the batterycondition.

The graphic 704 also includes numerical outputs for a number ofattributes of the motor, drill bit and drill string. For example, thegraphic 704 includes numerical outputs for the motor output RPMs, thedrill string RPMs, the drill bit RPMs, the weight on bit, the rate ofpenetration, the flow rate and the motor output torque. The graphic 704also includes numerical outputs for the depth, inclination and azimuthof the well bore.

The GUI screen 700 also includes a graphic 707 that summarizes thedrilling efficiency. The graphic 707 includes a description of theformation being cut (including name and rock strength). The graphic 707also includes numerical output regarding the optimum, current andaverage for the bit RPM, weight on bit and torque. The graphic 707 alsoincludes a description of the predicate, current and average rate ofpenetration.

The GUI screen 700 includes a graphic 709 that includes a number ofbuttons. One button allows for a tallybook application to be opened toallow this data to be input therein. Another button allows for a reportto be generated based on the data for this drilling operation. Anotherbutton allows for a display of the rotary steerable drilling toolutilities.

FIG. 8 illustrates a graphical user interface (GUI) screen that allowsfor controlling and monitoring of a directional drillingoperation/simulation, according to some other embodiments of theinvention. A GUI screen 800 has some of the same graphics as the GUIscreens 300, 400, 500, 600 and 700. In addition, the GUI screen 800includes some additional graphics.

The GUI screen 800 includes a graph 802 that illustrates the bit RPMvariation over time. The graph 802 includes an optimum upper limit andan optimum lower limit for this variation. The graphic 804 is similar tothe graphic 704. However, the graphic 708 is replaced with a graphic806, which includes an illustration of a meter for the current bit RPM.This meter may be changed to monitor the motor RPM, the drill stringRPM, the weight on bit, cyclic bending stress (fatigue) loading ondrilling assembly components, etc.

FIG. 9 illustrates a report generated for a directional drillingoperation/simulation, according to some embodiments of the invention. Areport 900 includes graphical and numerical outputs that include datafor the drilling (such as depth, rate of penetration, flow rates, etc.).The report 900 also includes attributes for the motor, the drill bit andthe mud (including model type, size, etc.). The report 900 includes amotor performance graph similar to graph 302 shown in FIG. 3. The report900 may be generated at any point during the drillingoperation/simulation.

FIGS. 10-11 illustrate another set of reports for a directional drillingoperation/simulation, according to some embodiments of the invention. Areport 1000 and a report 1100 provide graphical, numerical and textoutput regarding the operations of the downhole drilling motor.Embodiment may perform numerical logic routines and combine the resultswith specific written sentences from system memory into written reports.In so doing, embodiments may reduce the burden on the user to firstevaluate numerical data and physical occurrences and then to producegrammatically and technically correct written reports. This advancedautomated text based reporting facility is referred to within theembodiment as “pseudo text” and “pseudo reporting” and has not beenavailable to the directional drilling process before. This facility isapplicable to real-time drilling operations and post-drillingapplications analysis.

While a number of different graphics have been shown across differentGUI screens, embodiments are not limited to those illustrated. Inparticular, less or more graphics may be included in a particular GUIscreen. The graphics described may be combined in any combination.Moreover, the different GUI screens are applicable to both real timedrilling operations and simulations.

Some embodiments provide load monitoring among the downhole components(including the load distribution between the drill bit and reamers). Insome embodiments, downhole drilling motors use a positive displacementtype helically lobed rotor and stator power units where, for a givenflow rate and circulating fluid properties, the operating differentialpressure developed across the power unit is directly proportional to thetorque produced by the power unit. The relationship between weight onbit (WOB) and differential pressure (ΔP) may be used in relation toassessing the torsional loading and rotation of drill bits—throughcorrelation with the specific performance characteristics (performancegraph) for the motor configuration (power unit) being used.

It is becoming increasingly common for operators to run hole openingdevices, such as reamers, in conjunction with motors for significanthole enlargement operations of up to +30%. The configuration of theseBHAs typically places 30 feet to 120 feet of drill collars, stabilizersand M/LWD equipment between the cutting structure of the bit and thecutting structure of the hole opening device or reamer. In layeredformations it is common for the each cutting structure to be in adifferent rock type causing wide variation in the WOB applied to eachcutting structure. The inability to monitor and correct the applicationof WOB vs. weight on reamer (WOR) has resulted in multiple catastrophictool failures and significant non productive time (NPT) costs tooperators and service providers alike. In some embodiments, the weightand torque applied to the reamer may be approximated and differentiatedfrom that which is applied to the bit. In some embodiments, the weightand torque applied to the reamer in comparison to the bit may bedisplayed in real time, recorded, etc.

In some embodiments, the configuration of the drilling operation is setto at least two configurations to establish two different data points.FIG. 12 illustrates a drilling operation wherein the reamer is notengaged and the drill bit is on the bottom, according to someembodiments of the invention. FIG. 12 illustrates a drill string 1202 ina borehole 1204 having sides 1210. The drill string 1202 includesreamers 1206A-1206B which are not extended to engage the sides 1210. Adrill bit 1208 at the end of the drill string 1202 is at the bottom 1212of the borehole 1204. In some embodiments, sensor(s) may determine thetorque at the surface. Moreover, sensor(s) may determine thedifferential pressure while at a normal operating flow rate with thedrill bit 1208 on-bottom, at a known WOB, with the reamers 1206A-1206Bnot engaged, to establish a primary data point. A second data point isthen established. In particular, the same parameters (surface torque anddifferential pressure) may be accessed, while the drill bit 1208 is onbottom drilling, at a different WOB, and the reamers 1206A-1206B are notengaged.

The two data points may be used to calculate the slope of a line. Inparticular, FIGS. 13-14 illustrate graphs of the torque relative to theoperating differential pressure for a downhole drilling motor, accordingto some embodiments of the invention. In the graphs 1300 and 1400, thedifference in differential pressure and the calculated slope are relatedto previously known functional characteristics of the specific powerunit (see the line 1302 in FIGS. 13-14). In some embodiments, anydeviation of the calculated slope or extension of the line beyond thecalculated intersection on the torque/A curve, is attributed to the holeopener/reamer and hence the torsional loading and rotational motion ofthe drill bit can be separated from that of other BHA components (seethe extension 1402 in FIG. 14).

In some embodiments, this distribution of the loads may be displayed inone of the GUI screens (as described above). These graphicalrepresentations may facilitate intervention prior to the onset ofstick-slip and lateral vibration. Moreover, this monitoring of thedistribution may allow for the approximating of the functionality ofadditional down hole instrumentation or that of an instrumented motorwithout providing additional down hole sensors, independent of andwithout altering existing motor designs.

In some embodiments, the interpretation of motor differential operatingpressure can be used to evaluate the forces required to overcome staticinertia and friction losses related to other tools which are run belowmotors, such as rotary steerable tools and adjustable gauge stabilizers.In many high angle and tight hole applications this can be an issuewhere differential pressure is applied to a drilling motor and theresulting torsional loading is then applied to the tools below themotor. However, rotation of the tools below the motor is notestablished. Thus, the frictional and tool weight losses are overcome bythe applied motor torsion and the tools abruptly begin to rotate. Thiscan cause mechanical loading issues with the tools below the motor interms of mechanical and electronic components within. Internal motorcomponents can also be adversely affected.

In some applications, the amount of power required to overcome themechanical loadings caused by the tools below the motor may leave only alimited amount of remaining power with which to undertake the drillingprocess. The graphical and numerical representations (as describedherein) may provide a real-time indication of this problem. Accordingly,directional drilling personnel may adjust drilling operations asrequired. In some applications tools run below motors may, at times,need to be operated on very low flow rates with small differentialpressures in order for such tools to be correctly configured or toperform certain functions.

Embodiments of the graphical and numerical representations may aid inthe above scenarios. The more subtle start-up and low level motoroperating aspects are often not observable at surface by the directionaldriller. Embodiments may process relevant data and through thesegraphical and numerical representations indicate fluctuations in thedrill bit rotation and in drilling motor output torque and RPMcharacteristics. Some embodiments may be applicable to rotary drillingassemblies where there is no drilling motor in the bottom hole drillingassembly.

In various embodiments, monitoring and control of directional drillingoperations and associated functions and simulations can be conducted ina hand mobile communication device. A hand mobile communication deviceis defined herein as a device that can communicate wirelessly and isstructured such that it is capable of mobility as a hand carried device.Hand mobile communication devices can include, but are not limited to, asmartphone, a tablet, and a laptop computer, each having a graphicaluser interface. A smartphone, an example of which is illustrated in FIG.15A, is a mobile phone having an operating system that provides foradvanced computing capabilities in the smartphone itself. The advancedcomputing capabilities include application programming interfaces (APIs)that run non-phone applications on the smartphone and integrate theseapplications with the operating system of the phone. The computingcapabilities provide for data processing and visual display screens thatcan be executed separate from a communications session. Smartphones caninclude touchscreens and web browsers. A tablet, an example of which isillustrated in FIG. 15B, is a one-piece mobile computer, typicallyoperated by a user via a touchscreen. The use of a touchscreen and avirtual keyboard allows a tablet to function as a mobile computersimilar to a laptop computer, but with reduced hardware components. Alaptop computer, an example of which is illustrated in FIG. 15C, isstructured in a housing that provides for increased number of hardwarecomponents relative to a tablet such as CD/DVD devices embedded in thelaptop computer and space for increased data storage. Though laptopcomputers are mobile computers, they generally are significantly largerin dimensions and weight than a tablet. Components of such hand mobilecommunication devices can be structured to function similar tocomponents discussed with respect to FIG. 2 to operate to performprocedures and techniques as taught herein with examples associated withFIGS. 1-14. The wireless capabilities of the hand mobile communicationdevices provide capabilities such that input components such as keyboardports, CDs, and other components of stationary computers may beeliminated. For instance, a smartphone and a tablet may not include a CDdevice or similar component for input from an external device, though alaptop computer can include such additional components. In addition tothe procedures and techniques discussed above, hand mobile communicationdevice can include APIs and stored instructions for additional analysisof data for a drilling operation at a drill site. The hand mobilecommunication device can provide for remote monitoring and control ofthe directional drilling operations at a drill site that is seamless andcan be conducted real-time.

A hand mobile communication device may be structured such that it isoperable to communicate wirelessly using different wireless transmissionmodes. For instance, a network interface of the hand mobilecommunication device can include components to wirelessly communicateover a wireless wide area network (WAN) such as provided by acommunications service provider. A network interface of the hand mobilecommunication device can also include components to wirelesslycommunicate over a wireless local area network (LAN) such as a Wi-Finetwork or by Bluetooth. The hand mobile communication device can useWi-Fi to couple to a local router to connect to a drilling site via aninternet connection. A Bluetooth can also be used to connect to adrilling site via an internet connection. The range of a Bluetoothconnection may be less than the Wi-Fi connection. Bluetooth, Wi-Fi, orother short-range wireless instrumentality may also be used to allow thehand mobile communication device to operate with local devices such as,but not limited to, external keyboards, external pointing devicesoperable with the GUI of the hand mobile communication device, printers,and local external data storage devices.

FIG. 16 illustrates an embodiment of an example architecture formonitoring and controlling a drilling operation at a drilling site 1615using a hand mobile communication device 1630. The drilling operationmay be a directional drilling operation of a drilling tool 1605. Thedrilling operation at the drilling site 1615 may be structured toinclude components similar to components at the drilling site of FIG. 1.The drilling tool 1605 may include a number of different sensors thatcollects data and sends the data to the surface. The data can includedata regarding the components of the drilling tool 1605, which caninclude data regarding the interior portions of the components of thedrilling tool 1605 and data regarding the portions of the drilling tool1605 that may directly contact the exterior of the drilling tool 1605.The data can also include data to provide analysis of the formations inwhich the drilling tool 1605 is operating. Such formation data can becollected from sensors that generate probe signals into the formationsand collect signals from the formations in response to the probesignals. The collected signals can include signals from ahead of thedirectional drilling operation.

The drill tool 1605 can send data to a field computer 1620 located atthe drilling site. The field computer 1620 may process some or all ofthe data from the drill tool 1605 and send the results to otherlocations, including the hand mobile communication device 1630. Thefield computer 1620 may forward the data without analyzing the dataand/or processing the data to the other locations, including the handmobile communication device 1630. Alternatively, the data may beanalyzed in a processing unit of the drilling tool 105 downhole and aset of results sent to the surface. The set of results may be furtherprocessed and/or analyzed at the field computer 1620 or at the otherlocations, including the hand mobile communication device 1630. If thefield computer 1620 functions solely as communication routing device, itmay be replaced with a communications router. The field computer 1620can be structured as a combination of computer and communicationsrouter. Communication between the field computer 1620 and the handmobile communication device 1630 via the wireless network(s) may includeother communication medium between the field computer 1620 and wirelessnetworks 1625.

The hand mobile communication device 1630 can receive the datawirelessly from a wireless network 1625 or combination of wirelessnetworks 1625. The combination of wireless networks 1625 can includecombinations of one or more wireless WANs and/or one or more wirelessLANS. The hand mobile communication device 1630 can display the data invarious formats on a GUI screen of the hand mobile communication device1630. Underlying APIs in the hand mobile communication device 1630 canoperate to manipulate the data to further analyze the drilling operationassociated with the drilling tool 1605 at the drilling site 1615 andshow the results of such further analysis on its GUI. If the data isdata that has not been analyzed prior to reception at the hand mobilecommunication device 1630, underlying APIs in the hand mobilecommunication device 1630 can operate to analyze the data and displayresults on the GUI of the hand mobile communication device 1630.

Commands generated in the hand mobile communication device 1630 can besent from the hand mobile communication device 1630, using the wirelessnetwork(s) 1625, back to the drill site 1615 to control the operation ofthe drilling tool 1605. The commands can be received at the fieldcomputer 1620 for further evaluation, for processing in a format to beforwarded to the drilling tool 1605, or for direct forwarding to thedrilling tool 1605. The field computer 1620 may be structured as acombination of computer and communications router.

In various embodiments, a process for performing a directional drillingoperation at a drilling site can be conducted in coordination with usinga hand mobile communications device. Such a process may includereceiving data wirelessly in the hand mobile communications device fromone or more sensors disposed downhole at the drilling site, wherein atleast one of the one or more sensors output data related to aperformance attribute of a downhole component. The downhole componentcan comprise part of a drill string that is used to perform thedirectional drilling operation. The downhole component may be from agroup consisting of a downhole drilling motor and a rotary steerabletool. The performance attribute can be selected from a group consistingof rotations per unit of time of the downhole component, operatingdifferential pressure across the downhole component, and torque outputof the downhole component. The data can be sent to the hand mobilecommunications device from one or more sensors via a field computer atthe drilling site or a communications routing device at the drillingsite. Such a method can include displaying the data in a numericalrepresentation, a graphical representation, or a combination ofgraphical representation and numerical representation on a GUI screen ofthe hand mobile communications device. Additional data associated withthe drilling operations can be sent wirelessly to the hand mobilecommunications device, where information based on the data is displayedon a GUI screen of the hand mobile communications device. Using the GUIscreen of the hand mobile communications device, control commands can begenerated and sent to the drilling site to control the directionaldrilling operation. In addition for some functions, commands can begenerated from the hand mobile communications device and sent to thedrilling site to control the directional drilling operation,automatically without using the GUI. Override control of automaticfunctions can be set in the hand mobile communications device.

FIG. 17 shows features of an embodiment of an example method to monitorand control directional drilling operations. Such a method and similarmethods can be performed using devices and architectures, as taughtherein. At 1710, data is wirelessly received in a mobile device, wherethe mobile device is a hand mobile communication device. (For ease ofdiscussion, the hand mobile communication device is referred to as themobile device in the following discussions regarding example features ofa method to monitor and control directional drilling operations.) Thedata can include performance data of a directional drilling operationdownhole at a drill site. The data can include data related to aperformance attribute of one or more drilling components used in thedirectional drilling operation and disposed downhole. The one or moredrilling components can include a drilling motor and a rotary steerabletool. The performance attribute can include one or more of rotations perunit of time of the one or more drilling components, operatingdifferential pressure across the one or more drilling components, ortorque output of the one or more drilling components. The mobile devicecan be a smartphone. The mobile device can be a tablet. The mobiledevice can be a laptop computer.

Receiving data in the mobile device can occur in response to a requestfor information on the drilling operation at a selected site sent to theappropriate system, locally at the drilling site or at a RTO center, orto a drilling tool at the selected drilling site. Digital instructions,data structures, object classes, or various combinations can be used inconjunction with the execution by one or more processors in the mobiledevice to initiate and conduct monitoring and control of the drillingoperations using the mobile device. On a GUI screen of the mobiledevice, a drilling application can be selected. On the GUI screen arequest to select a drilling site can projected. The drilling site canbe selected using an input that identifies a selected drilling site byinputting an identification of the drilling site or from a drop-down boxon the GUI screen with a set of possible drilling sites. Upon selectionof the drilling site, the mobile device can establish communication withthe appropriate system or drilling tool at the selected drilling site tosend the request for information. The request can be sent as a pollingactivity in which the request is sent automatically at fixed periods oftime to selected drilling sites that have been previously selected.

Receiving data in the mobile device can include receiving the data overa secure communication path with a communication unit at the drillingsite. Receiving the data over the secure communication path can includeconducting an authentication of the mobile device or user of the mobiledevice using a third party authentication process. The third partyauthentication process can use a secure server in which a securecommunication is established with the mobile device over a wirelessnetwork, while the server may communicate with the communication unit atthe drilling site over a land-based network. Use of the land-basednetwork may include use of the Internet.

At 1720, a representation of the data is displayed on the GUI screen ofthe mobile device. Multiple representations of the data can be displayedindividually in response to signals actuated from the interface screenor a user input device of the mobile device. These multiplerepresentations of the data may include selected portions of the data indifferent selected formats as different pages presented on the GUIscreen of the mobile device. The GUI screen can be a touchscreen. Atouch screen can be arranged to provide a user input device on thescreen. Some hand mobile communication devices can include build-intypewriter-like keys, which can be physically actuated. The keys may bearranged as a qwerty keyboard. Displaying the representation of the datacan include displaying in a graphical presentation, a numericalpresentation, or a combination of a numerical presentation and agraphical presentation on the graphical user interface screen of themobile device. Displaying the representation of the data can includedisplaying the representation of the data on the GUI screen of themobile device during performance of the directional drilling operation.Displaying the representation of the data on the GUI screen of themobile device can include displaying a graphical representation of adownhole component disposed as part of a drill string that showsanimated movement in an interior of the downhole component. Displayingthe representation of the data can include displaying an image offormations with respect to a drilling tool of the directional drillingoperation. Displaying the image can include displaying a projected pathof the drilling tool in the formations. Displaying the projected path ofthe drilling tool in the formations can include displaying the projectedpath as an animation showing the creation and progress of the path.Displaying the representation of the data can include displaying animage of formations represented by characteristics of the formations orrelationships of the drilling operation to the formations such as, butnot limited to, values of resistivity, values of porosity, values oftrue vertical direction (TVD) of the drilling, and other values ofparameters of the formations and/or drilling operation.

The data to be displayed can be sent wirelessly to the mobile device,where the data is stored on the mobile device. This data can be modifiedon the mobile device and used to generate additional information on themobile device to analyze the data relative to the drilling operation,including drilling tool properties and functions, properties of theformations, and relationships of the drilling tool to the formations.The processed data can be displayed in various representations on theGUI of the mobile device. Alternatively, each representation can be sentfrom a computer at the drilling site, a RTO center, or other sources onan individual basis in a data streaming manner to the mobile device.Interactive commands can be generated using the GUI of the mobile deviceand sent to the computer that provides the data, where analysis and datamodification is conducted on the computer with the results sent back tothe mobile device according to a representation format for the results.

A method to monitor and control directional drilling operations can alsoinclude transmitting, based on the data sent to the hand mobilecommunication device, control commands from the hand mobilecommunication device to a control unit associated with the directionaldrilling operation at the drill site to control one or more drillingtasks of the directional drilling operation based on the controlcommands. A method to monitor and control directional drillingoperations can also include conducting, in the hand mobile communicationdevice, simulations of the directional drilling operation downhole atthe drill site. These simulations can be used to analyze and directfurther tasks for the drilling operation. Conducting the simulations inthe hand mobile communication device can include conducting thesimulations as a training tool, which may allow the use of actual datafor training purposes. A method to monitor and control directionaldrilling operations can also include transmitting commands from themobile device to a drilling tool of the directional drilling operationto modify operation of the drilling tool or collect additional data. Amethod to monitor and control directional drilling operations can alsoinclude performing the directional drilling operation and directing thedirectional drilling operation from the mobile device.

FIG. 18 shows example components of a hand mobile communication device1800 operable to monitor and control drilling operations at a drillingsite. The hand mobile communication device 1800 can include a processorunit 1840 having one or more processors and a memory unit 1844operatively coupled to the processor unit 1840, the memory unit 1844having instructions stored thereon, which when executed by the processorunit 1840, causes the hand mobile communication device 1800 to performoperations to monitor, to control, or to monitor and control adirectional drilling operation downhole at a drill site. The hand mobilecommunication device 1800 has a wireless communications unit operable toreceive signals providing data, the data including performance data ofthe directional drilling operation downhole at the drill site, andoperable to transmit signals over a wireless network. The wirelesscommunications unit can be included in a communications unit 1845 thatcan be structured with a number of different types of network interfacesor structured for wireless communication only. The hand mobilecommunication device 1800 has a GUI screen 1846 operable to display arepresentation of the data received. The hand mobile communicationdevice 1800 has a housing containing the processor unit 1840, thegraphical user interface screen 1846, the memory unit 1844, and thecommunications unit 1845 having the wireless communications unit, thehousing being a structure capable of being hand carried.

The hand mobile communication device 1800 may include a graphicscontroller 1842 to operate the GUI screen 1846. The hand mobilecommunication device 1800 may include selection devices 1848 to operatein conjunction with the GUI screen 1846, where such selection devices1848 can include, but are not limited to, instrumentality to operate theGUI screen 1846 as a touchscreen, instrumentality to operate the GUIscreen 1846 with external devices including, but not limited to, acomputer mouse and keyboard. The hand mobile communication device 1800includes peripheral devices 1849, which can include circuits that mayoperate in conjunction with the processor unit 1840, the memory unit1844, the communications unit 1845, the GUI screen 1846, the graphicscontroller 1842, or permutations of these components to monitor,control, or monitor and control drilling operations at drilling sites.The hand mobile communication device 1800 includes electronic apparatus1847, which can be used in conjunction with the processor unit 1840 toperform tasks associated with the hand mobile communication device 1800,where the tasks are in addition to tasks to monitor, control, or monitorand control drilling operations at drilling sites.

The hand mobile communication device 1800 can also include a bus 1843,where the bus 1843 provides electrical conductivity among the handmobile communication device 1800. The bus 1843 can include an addressbus, a data bus, and a control bus, each independently configured. Thebus 1843 can also use common conductive lines for providing one or moreof address, data, or control, the use of which can be regulated by theprocessor unit 1840. The bus 1843 can be configured such that thecomponents of the hand mobile communication device 1800 can bedistributed within the housing structured to be hand carried.

The memory unit 1844 can include instructions to send commands to adrilling tool at the drill site to control a directional drillingoperation of the drilling tool of the drilling operation. The memoryunit 1844 can include instructions to simulate the directional drillingoperation downhole at the drill site. The hand mobile communicationdevice 1800 can be a smartphone. The hand mobile communication device1800 can be a tablet. The hand mobile communication device 1800 can be alaptop computer. Further, the hand mobile communication device 1800 canbe structured to monitor, control, or monitor and control drillingoperations at drilling sites in a manner similar to or identical to thedevices, schemes, and architectures discussed herein.

In the description, numerous specific details such as logicimplementations, opcodes, means to specify operands, resourcepartitioning/sharing/duplication implementations, types andinterrelationships of system components, and logicpartitioning/integration choices are set forth in order to provide amore thorough understanding of embodiments of the present invention. Itwill be appreciated, however, by one skilled in the art that embodimentsof the invention may be practiced without such specific details. Inother instances, control structures, gate level circuits and fullsoftware instruction sequences have not been shown in detail in ordernot to obscure the embodiments of the invention. Those of ordinary skillin the art, with the included descriptions will be able to implementappropriate functionality without undue experimentation.

Although specific embodiments have been illustrated and describedherein, it will be appreciated by those of ordinary skill in the artthat any arrangement that is calculated to achieve the same purpose maybe substituted for the specific embodiments shown. Various embodimentsuse permutations and/or combinations of embodiments described herein. Itis to be understood that the above description is intended to beillustrative, and not restrictive, and that the phraseology orterminology employed herein is for the purpose of description.Combinations of the above embodiments and other embodiments will beapparent to those of skill in the art upon studying the abovedescription.

What is claimed is:
 1. A method comprising: receiving data wirelessly ina mobile device, the data including performance data of a directionaldrilling operation downhole at a drill site, the mobile device being ahand mobile communication device; and displaying a representation of thedata on a graphical user interface screen of the mobile device includingdisplaying a graphical representation of a downhole component disposedas part of a drill string that shows animated movement in an interior ofthe downhole component.
 2. The method of claim 1, wherein the methodincludes transmitting, based on the data, control commands from themobile device to a control unit associated with the directional drillingoperation at the drill site to control one or more drilling tasks of thedirectional drilling operation based on the control commands.
 3. Themethod of claim 1, wherein the method includes displaying multiplerepresentations of the data individually in response to signals actuatedfrom the interface screen or a user input device of the mobile device.4. The method of claim 1, wherein displaying the representation of thedata includes displaying in a graphical presentation, a numericalpresentation, or a combination of a numerical presentation and agraphical presentation on the graphical user interface screen of themobile device.
 5. The method of claim 1, wherein displaying therepresentation of the data includes displaying the representation of thedata on the graphical user interface screen of the mobile device duringperformance of the directional drilling operation.
 6. The method ofclaim 1, wherein displaying the representation of the data includesdisplaying an image of formations with respect to a drilling tool of thedirectional drilling operation.
 7. The method of claim 6, whereindisplaying the image includes displaying a projected path of thedrilling tool in the formations.
 8. The method of claim 6, whereindisplaying the projected path of the drilling tool in the formationsincludes displaying the projected path as an animation showing thecreation of the path.
 9. The method of claim 1, wherein the mobiledevice is a smartphone.
 10. The method of claim 1, wherein the mobiledevice is a tablet.
 11. The method of claim 1, wherein the mobile deviceis a laptop computer.
 12. The method of claim 1, wherein the methodincludes conducting, in the mobile device, simulations of thedirectional drilling operation downhole at the drill site.
 13. Themethod of claim 12, wherein conducting, in the mobile device, thesimulations includes conducting the simulations as a training tool. 14.The method of claim 13, wherein the method includes transmittingcommands from the mobile device to a drilling tool of the directionaldrilling operation to modify operation of the drilling tool or collectadditional data.
 15. The method of claim 1, wherein receiving datawirelessly in the mobile device includes receiving the data over asecure communication path with a communication unit at the drillingsite.
 16. The method of claim 15, wherein receiving the data over thesecure communication path includes conducting an authentication of themobile device or user of the mobile device using a third partyauthentication process.
 17. The method of claim 1, wherein the dataincludes data related to a performance attribute of one or more drillingcomponents used in the directional drilling operation and disposeddownhole.
 18. The method of claim 17, wherein the one or more drillingcomponents includes a drilling motor and a rotary steerable tool. 19.The method of claim 17, wherein the performance attribute includes oneor more of rotations per unit of time of the one or more drillingcomponents, operating differential pressure across the one or moredrilling components, or torque output of the one or more drillingcomponents.
 20. The method of claim 1, wherein the method includesperforming the directional drilling operation and directing thedirectional drilling operation from the mobile device.
 21. Amachine-readable device including instructions stored thereon, whichwhen executed by a processor, causes a mobile device to performoperations comprising operations to: receive data wirelessly in themobile device, the data including performance data of a directionaldrilling operation downhole at a drill site, the mobile device being ahand mobile communication device; display a representation of the dataon a graphical user interface screen of the mobile device; and display agraphical representation of a downhole component disposed as part of adrill string that shows animated movement in an interior of the downholecomponent.
 22. The machine-readable device of claim 21, wherein theinstructions includes instructions to transmit, based on the data,control commands from the mobile device to a control unit associatedwith the directional drilling operation at the drill site to control oneor more drilling tasks of the directional drilling operation based onthe control commands.
 23. The machine-readable device of claim 21,wherein the instructions include instructions to display multiplerepresentations of the data individually in response to signals actuatedfrom the interface screen or a user input device of the mobile device.24. The machine-readable device of claim 21, wherein displaying therepresentation of the data includes displaying in a graphicalpresentation, a numerical presentation, or a combination of a numericalpresentation and a graphical presentation on the graphical userinterface screen of the mobile device.
 25. The machine-readable deviceof claim 21, wherein displaying the representation of the data includesdisplaying the representation of the data on the graphical userinterface screen of the mobile device during performance of thedirectional drilling operation.
 26. The machine-readable device of claim21, displaying the representation of the data includes displaying animage of formations with respect to a drilling tool of the directionaldrilling operation and displaying a projected path of the drilling toolin the formations.
 27. The machine-readable device of claim 21, whereinthe mobile device is a smartphone, a tablet, or a laptop computer. 28.The machine-readable device of claim 21, wherein the instructionsinclude instructions to conduct, in the mobile device, simulations ofthe directional drilling operation downhole at the drill site.
 29. Themachine-readable device of claim 21, wherein the instructions includeinstructions to transmit commands from the mobile device to a drillingtool of the directional drilling operation to modify operation of thedrilling tool or collect additional data.
 30. The machine-readabledevice of claim 21, wherein the data includes data related to aperformance attribute of one or more drilling components used in thedirectional drilling operation and disposed downhole.
 31. Themachine-readable device of claim 30, wherein the one or more drillingcomponents includes a drilling motor and a rotary steerable tool. 32.The machine-readable device of claim 30, wherein the performanceattribute includes one or more of rotations per unit of time of the oneor more drilling components, operating differential pressure across theone or more drilling components, or torque output of the one or moredrilling components.
 33. The machine-readable device of claim 21,wherein the instructions include instructions to direct the directionaldrilling operation from the mobile device.
 34. A mobile devicecomprising: a processor unit having one or more processors; a memoryunit operatively coupled to the processor unit, the memory unit havinginstructions stored thereon, which when executed by the processor unit,causes the mobile device to perform operations to monitor, to control,or to monitor and control a directional drilling operation downhole at adrill site; a wireless communications unit operable to receive signalswirelessly providing data, the data including performance data of thedirectional drilling operation downhole at the drill site, and operableto transmit signals over a wireless network; a graphical user interfacescreen operable to display a representation of the data and to display agraphical representation of a downhole component disposed as part of adrill string that shows animated movement in an interior of the downholecomponent; and a housing containing the processor unit, the graphicaluser interface screen, the memory unit, and the wireless communicationsunit, the housing being a structure capable of being hand carried. 35.The mobile device of claim 34, wherein the mobile device is asmartphone.
 36. The mobile device of claim 34, wherein the mobile deviceis a tablet.
 37. The mobile device of claim 34, wherein the mobiledevice is a laptop computer.
 38. The mobile device of claim 34, whereininstructions include instructions to simulate the directional drillingoperation downhole at the drill site.
 39. The mobile device of claim 34,wherein instructions include instructions to send commands to a drillingtool at the drill site to control a drilling operation of the drillingtool.